Configurations and methods for gas condensate separation from high-pressure hydrocarbon mixtures

• US 9,132,379 B2
• Filed: 11/06/2007
• Issued: 09/15/2015
• Est. Priority Date: 11/09/2006
• Status: Active Grant

• Current Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John
• Primary Examiner(s): Pettitt, John F
• Assistant Examiner(s): ALOSH, TAREQ M
• Application Number:
  US12/446,672
• Publication Number:
  US 20100000255A1
• Time in Patent Office: 2,870 Days
• Field of Search: 626/17, 626/18, 626/20, 626/22, 62/98, 626/25, 626/30, 626/32, 626/35, 951/91, 952/06, 952/07, 95/92, 95/94, 585/800, 585/867, 208/341, 208/346, 208/92, 208/96, 208/100, 208/101, 208/208.R, 208/209, 208/337, 208/351, 208/368, 962/43, 202/158, 202/168, 203/87, 203/98
• US Class Current: 1/1
• CPC Class Codes: B01D 2256/24 Hydrocarbons
• CPC Class Codes: B01D 2258/0216 from CVD treatment or semi-conductor manufacturing
• CPC Class Codes: B01D 47/06 Spray cleaning
• CPC Class Codes: B01D 53/14 by absorption
• CPC Class Codes: B01D 53/1418 Recovery of products
• CPC Class Codes: B01D 53/1487 Removing organic compounds
• CPC Class Codes: C07C 7/152 by forming adducts or complexes
• CPC Class Codes: C07C 7/156 with solutions of copper salts
• CPC Class Codes: C10G 21/00 Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents C10G17/00, C10G19/00 take precedence
• CPC Class Codes: C10G 2300/1025 Natural gas
• CPC Class Codes: C10G 5/04 with liquid absorbents
• CPC Class Codes: C10L 3/10 Working-up natural gas or synthetic natural gas
• CPC Class Codes: C10L 3/102 of acid contaminants
• CPC Class Codes: C10L 3/104 Carbon dioxide
• CPC Class Codes: C10L 3/12 Liquefied petroleum gas liquefying by pressure and cold treatment F25J

Abstract

Contemplated configurations and methods for gas processing use a refluxed absorber that receives a liquid and a vapor hydrocarbon feed. The absorber further receives a stripping medium that is at least in part formed from a vapor portion of a stabilizer overhead and also receives a scrubbing medium that is at least in part formed from a liquid portion of the stabilizer overhead. Most preferably, the absorber overhead is maintained at a temperature near or even below the hydrate point of the feed.

Claims

1. A method of processing a high pressure hydrocarbon feed in a refluxed absorber and a stabilizer, wherein the hydrocarbon feed includes at least 0.5 mol % of C6+ hydrocarbons, comprising:

separating the hydrocarbon feed into a vapor portion and a liquid portion;

feeding the vapor portion and the liquid portion of the high pressure hydrocarbon feed to the refluxed absorber, cooling an overhead product of the refluxed absorber to produce a two-phase mixture, and separating the two-phase mixture to generate a reflux to the refluxed absorber,

wherein cooling the overhead product is performed to maintain an overhead temperature of the refluxed absorber at or below hydrate temperature of the hydrocarbon feed;

wherein the refluxed absorber produces a C6+ enriched bottom product and a C6+ depleted overhead product;

separating the C6+ enriched bottom product in a first separator into a liquid portion of the C6+ enriched bottom product and a vapor portion of the C6+ enriched bottom product;

feeding the liquid portion of the C6+ enriched bottom product to the stabilizer;

feeding the vapor portion of the C6+ enriched bottom product to a second separator;

feeding a stabilizer overhead to the second separator;

feeding a stripping medium to a bottom portion of the refluxed absorber, wherein the stripping medium is at least in part formed from a vapor portion of the stabilizer overhead; and

,

feeding a scrubbing medium above the bottom portion of the refluxed absorber, wherein the scrubbing medium is at least in part formed from a liquid portion of the stabilizer overhead.

2. The method of claim 1 wherein the stripping medium further comprises a vapor portion of a bottom product of the refluxed absorber.

3. The method of claim 1 wherein the scrubbing medium further comprises a vapor portion of a bottom product of the refluxed absorber.

4. The method of claim 1 wherein the stripping medium is compressed by a compressor prior to entry into the refluxed absorber.

5. The method of claim 1 wherein the refluxed absorber produces a C6+ enriched bottom product and a C6+ depleted overhead product, further comprising a step of separating the C6+ enriched bottom product in a first separator into a liquid portion of the C6+ enriched bottom product and a vapor portion of the C6+ enriched bottom product, and further comprising a step of feeding the liquid portion of the C6+ enriched bottom product to the stabilizer.

6. The method of claim 5 further comprising a step of feeding the vapor portion of the C6+ enriched bottom product to a second separator.

7. The method of claim 6 further comprising a step of feeding the stabilizer overhead to the second separator.

8. The method of claim 1 further comprising a step of providing a dehydrating section to the refluxed absorber and maintaining the overhead temperature of the refluxed absorber below hydrate temperature of the hydrocarbon feed.

9. The method of claim 1 wherein the high pressure hydrocarbon feed has a pressure of between 800 and 1200 psig.

10. A gas treatment plant comprising:

a feed gas separator configured to receive a C6+ containing feed gas and further configured to produce a liquid portion and vapor portion;

a refluxed absorber that is configured to receive the liquid portion and vapor portion of the C6+ containing feed gas at a pressure of equal or greater than 600 psig, and that is further configured to produce a C6+ enriched bottom product and a C6+ depleted overhead product;

a condenser fluidly coupled to the refluxed absorber and configured to receive and cool the C6+ depleted overhead product to thereby form a two-phase mixture, and a reflux separator configured to separate a liquid reflux from the C6+ depleted overhead product;

a first separator fluidly coupled to the refluxed absorber to receive the C6+ enriched bottom product and to produce a liquid portion of the C6+ enriched bottom product and a vapor portion of the C6+ enriched bottom product;

a stabilizer fluidly coupled to the first separator and configured to receive the liquid portion of the C6+ enriched bottom product and to produce an overhead;

a second separator fluidly coupled to the stabilizer to receive the overhead and to produce a vapor portion of the overhead and a liquid portion of the overhead;

wherein the refluxed absorber is further configured to receive the vapor portion of the overhead as stripping medium at a bottom portion of the refluxed absorber, and to receive the liquid portion of the overhead as a scrubbing medium above the bottom portion of the refluxed absorber; and

wherein the condenser is configured to cool the C6+ depleted overhead product to a temperature effective to maintain an overhead temperature of the refluxed absorber at about or below hydrate temperature of the hydrocarbon feed.

11. The plant of claim 10 further comprising a first compressor fluidly coupled to the second separator and configured to compress the vapor portion of the overhead prior to entry into the refluxed absorber.

12. The plant of claim 10 further comprising a conduit fluidly coupled to the first and second separators to feed the vapor portion of the C6+ enriched bottom product from the first separator to the second separator.

13. The plant of claim 10 further comprising a pressure reduction device that is fluidly coupled to the refluxed absorber and first separator and configured to provide a flashed C6+ enriched bottom product to the first separator.

14. The plant of claim 10 further comprising a second compressor fluidly coupled to the stabilizer and configured to compress the vapor portion of the overhead prior to entry into the second separator.

15. The plant of claim 10 wherein the refluxed absorber further comprises a glycol dehydration unit.

16. The plant of claim 10 wherein the refluxed absorber is configured to operate at a pressure of about 1000 psig to 1200 psig.

17. The plant of claim 10 wherein the refluxed absorber is configured to separately receive the vapor portion of a feed gas and the liquid portion of the feed gas.